Master control system with remote monitoring for handling tubulars

ABSTRACT

A master control system with remote monitoring that can perform, monitor, and control operations of a portable rig with a pipe handler as the pipe handler installs tubulars into a drill string or breaks out tubulars from a drill string for a wellbore. The master control system can include a processing device communicatively coupled to a data storage. The processing device receives a communication associated with a component of a portable rig. The processing device determines a position of the component of the portable rig based on the received communication. The processing device further provides an executive dashboard that includes at least one drilling rig function associated with the component of the portable rig. The processing device also initiates the portable rig to perform the at least one drilling rig function associated with the component of the portable rig.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation of U.S. patent application Ser. No.13/679,960, filed on Nov. 16, 2012, which claims the benefit of U.S.Provisional Application No. 61/587,438, filed on Jan. 17, 2012, entitled“MASTER CONTROL SYSTEM WITH REMOTE MONITORING FOR HANDLING TUBULARS,”the content of which is incorporated herein by reference in itsentirety.

FIELD

The present embodiments generally relate to a master control system withremote monitoring for handling tubulars.

BACKGROUND

A need exists for a master control system that allows one or more usersto remotely monitor the installation, removal, or both of one or moretubulars.

A further need exists for a master control system that allows at leastpartial automation of rig operation to provide a safe work environmentfor rig personnel.

The present embodiments meet these needs.

BRIEF DESCRIPTION OF THE DRAWINGS

The detailed description will be better understood in conjunction withthe accompanying drawings as follows:

FIG. 1 depicts a schematic of a master control system configured toperform an operation on a tubular according to one or more embodiments.

FIG. 2 depicts a schematic of a portion of the master control system ofFIG. 1 with a retracted top drive.

FIGS. 3A and 3B depict a detailed schematic of data storage according toone or more embodiments.

FIG. 4 depicts a detailed schematic of data storage according to one ormore embodiments.

FIG. 5 is a top view of an embodiment of the drilling rig, vertical pipehandler, and horizontal to vertical pipe handler that can be controlledby the master controller.

The present embodiments are detailed below with reference to the listedFigures.

DETAILED DESCRIPTION OF THE EMBODIMENTS

Before explaining the present system in detail, it is to be understoodthat the system is not limited to the particular embodiments and that itcan be practiced or carried out in various ways.

The present embodiments relate to a master control system with remotemonitoring for handling one or more tubulars.

The master control system can include a server with a processorconnected to a data storage, which can be on a network, connectable to acomputing cloud, or both, for installing tubulars connectable into adrill string into a wellbore by a drilling rig.

The master control system can include a server with a processorconnected to a data storage with a plurality of computer instructionsfor removing tubulars from a wellbore and breaking down a drill string.

The master control system can be used to allow remote monitoring duringinstallation of one or more tubulars in a wellbore using a drilling rig.The remote monitoring can be 100 yards from the well bore or hundreds ofmiles from the well bore.

The invention provides increased safety and reduced accidents around therig.

The invention allows a home office to act quickly when a rig may beexperiencing difficulty in making up tubulars into a drill string orbreaking down a drill string.

The master control system can include a server. The server can be alaptop, a PC, or another type of computing processor that communicatesto data storage. The data storage and the processor that form the servercan be in communication with a network and a data storage.

The server can be based in a computing cloud. The server can be in thehome office of a driller, on a network.

The network can be a local area network, a wireless network, a satellitenetwork, a similar network, or combinations thereof.

The server can be in communication with multiple client devicessimultaneously, or with a single client device via the network. Theclient devices can be cell phones, laptops, PCs, desk top processorswith data storage, tablets, and similar devices that can be wired orwirelessly connected to the network or the computing cloud and beconfigured to present an executive dashboard of rig functions, verticalpipe handler functions, and horizontal to vertical pipe handlerfunctions, to a user of the client device.

The server can be in communication with a second client device via thenetwork, a computing cloud, or both.

The second client device can be a device similar to the first clientdevice, or different than the first client device. The second clientdevice can be configured to present an executive dashboard of rigfunctions, vertical pipe handler functions, and horizontal to verticalpipe handler functions to a user of the client device.

The data storage can include computer instructions to managesynchronized functions of the rig's hoist system and a top drive, aswell as the functions of a vertical pipe handler, and a horizontal tovertical pipe handler which are operationally connected together inseries.

The computer instructions in the data storage can receive inputs frommonitoring devices connected with components of the drilling rig, andcan use the received inputs to determine a location of the top drive andvertical pipe handler, a position of the horizontal to vertical pipehandler, and a speed of the hoist system.

Sensors on the rig can also be used with computer instructions in theserver to count the number of tubulars that are used on the drill stringand to measure the length of each tubular being connected to or removedfrom a drill string.

For example, one or more sensors can be placed at one or morepredetermined locations on a mast to detect if the top drive isproximate to the crown, to the tubular, or to the base of the mast.

One or more sensors on the rig can measure a rotational speed of thehoist system.

One or more sensors on the rig can determine the location of the topdrive and computer instructions in the server can be used tocontinuously calculate the location of the top drive and the depth ofthe tubular in the well bore based on a sensed position and rotationalspeed of the hoist system.

In operation, the vertical pipe handler and the horizontal to verticalpipe handler can be actuated based on the sensed location of the topdrive.

The data storage of the master control system can include computerinstructions to determine when one or more tubulars are disposed on thehorizontal to vertical pipe handler and to instruct the horizontal tovertical pipe handler to grab the one or more tubulars.

For example, the computer instructions in the data storage can receiveinputs provided to the server by one or more sensors on the horizontalto vertical pipe handler, and when a signal from the sensors indicatesthat tubulars are disposed thereon, the computer instructions caninstruct a processor of the server to actuate one or more cylinders onthe horizontal to vertical pipe handler to grip the tubular.

The data storage can include computer instructions to raise thehorizontal to vertical pipe handler to a vertical position from aninitial horizontal position.

For example, these computer instructions can instruct the server toinitiate movement of the horizontal to vertical pipe handler from asubstantial horizontal position to a substantially vertical positiononce a sensor detects that a gripper has fully closed about the one ormore tubulars on the horizontal to vertical pipe handler.

The data storage can include computer instructions to extend arms of thevertical pipe handler to grab a tubular from the horizontal to verticalpipe handler, and to rotate and lift the tubular for positioning at awell center. For example, these computer instructions can receive inputson the location of the horizontal to vertical pipe handler, determinewhen the horizontal to vertical pipe handler is in an operativeposition, and instruct the processor to send one or more signals to thevertical pipe handler instructing the vertical pipe handler to extendtop and bottom pivoting arms of the vertical pipe handler to grab thetubular from the horizontal to vertical pipe handler.

The data storage can include computer instructions to lower the topdrive to an end of the tubular. For example, these computer instructionscan compare the calculated or detected location of the top drive to apredetermined location, and instruct the processor to instruct a controlof the hoist system to lower the top drive until the predeterminedlocation is reached enabling the tubular to be connected to the topdrive.

The data storage can include computer instructions to engage the topdrive with the tubular making up the connection. For example, thesecomputer instructions can instruct the top drive to secure to thetubular in a manner known to one skilled in the art.

The data storage can include computer instructions to rotate the tubularwith the top drive and drive the tubular into the wellbore. For example,these computer instructions can instruct the processor to instruct thehoist system to lower the top drive when a signal is received indicatingthat the top drive has secured to the tubular.

The data storage can include computer instructions to retract thetravelling block with the top drive, and to travel the top drive to astart position. The start position can be adjacent a crown when runningtubulars into the wellbore. For example, these computer instructions caninstruct the processor to instruct one or more arms connected to thetraveling block to move the travelling block with the top drive into achannel formed in a mast when it is determined that the top drive andtraveling block are aligned with a space.

The data storage can include computer instructions to extend arms of thevertical pipe handler to grab a subsequent tubular from the horizontalto vertical pipe handler, and rotate and lift the subsequent tubular forpositioning at the well center.

The master control system can retract the traveling block into a recessin the mast and actuate the vertical pipe handler simultaneously.

The data storage can include computer instructions to lower the topdrive to an end of the subsequent tubular. For example, these computerinstructions can instruct the server to send a signal to the hoistsystem to lower the top drive upon receiving a signal indicating thatthe subsequent tubular member is in position to be engaged by the topdrive.

The data storage can include computer instructions to engage the topdrive with the subsequent tubular making up the connection.

The data storage can include computer instructions to rotate thesubsequent tubular with the top drive and make up a connection with thetubular using a roughneck secured to a drilling floor. For example,these computer instructions can instruct the server to initiate rotationof the top drive when a signal is received indicating that the tubularmember is engaged by hydraulic power tongs, and to move the subsequenttubular member towards the roughneck.

The data storage can include computer instructions to drive the tubularsinto the well bore.

The data storage can include computer instructions to retract thetravelling block with the top drive to the start position.

The data storage can include computer instructions to perform theforegoing operations on any number of tubulars.

The data storage can be configured to cause any number of tubulars to beran downhole or removed from the wellbore.

The data storage can be configured to reset the horizontal to verticalpipe handler when the horizontal to vertical pipe handler is depleted oftubulars.

The data storage can include computer instructions to lower thehorizontal to vertical pipe handler to a trailer frame. For example,these computer instructions can instruct the processor to lower thehorizontal to vertical pipe handler to the trailer frame when an inputis received that all tubulars have been removed from the horizontal tovertical pipe handler.

The master control system with remote monitoring can be configured toaid with the removal of tubulars from the well bore.

The data storage can be configured to include computer instructions tomanage synchronized functions of the hoist system, the top drive, thevertical pipe handler, and the horizontal to vertical pipe handler.

The data storage can be configured to lower the top drive to an end of atubular disposed in the wellbore.

The data storage can be configured to engage the top drive with thetubular making up a connection.

The data storage can be configured to retract the tubular from thewellbore using the top drive.

The data storage can be configured to determine when the hydraulic powertongs have engaged the tubular, and to operate the hydraulic power tongsto break out the tubular from subsequent tubulars located in thewellbore.

The data storage can be configured to engage the tubular with thevertical pipe handler.

The data storage can be configured to retract the vertical pipe handlerto place the tubular in a setback

The data storage can also include computer instructions to track howmany tubulars are placed in the wellbore.

In one or more embodiments, the horizontal to vertical pipe handler canhave two arms. Each arm of the horizontal to vertical pipe handler canbe configured to hold independently raise the tubulars held therein to avertical position.

Turning now to the Figures, FIG. 1 depicts a schematic of the mastercontrol system configured to perform an operation on a tubular accordingto one or more embodiments.

The master control system can include a server 602 a which includes aprocessor and communicates to data storage 610 a that is connected via anetwork 608.

Similarly, the master control system can include a cloud based server602 b which can include a processor and can communicate to cloud baseddata storage 610 b that is in a computing cloud 687 and can communicatewith the network 608.

The servers 602 a and 602 b can be configured to execute computerinstruction in one or more data storages 610, and to communicate withdevices via the network 608. The servers 602 a and 602 b can be aPENTIUM™ processor or similar device.

The one or more data storages 610 a and 610 b can be connected to,integrated with, or otherwise in communication with the servers 602 aand 602 b.

In embodiments, a cloud based server, a non-cloud based server, or bothcan be used simultaneously.

Similarly, in embodiments, a cloud based data storage, a non-cloud basedata storage, or both can be used simultaneously.

A first client device 660 and a second client device 670 can be incommunication with the network 608, the computing cloud 687 or bothsimultaneously.

The first client device 660 is configured for receiving and presentingan executive dashboard 663 a which displays not only rig functions to afirst user but also vertical pipe handler operational information andhorizontal to vertical pipe handler operational information to the firstuser 667.

The second client device 670 is configured for receiving and presentingthe executive dashboard 663 b which is identical to the executivedashboard 663 a of the first client device. Like the executive dashboard663 a, executive dashboard 663 b displays not only rig functions to asecond user but also vertical pipe handler operational information andhorizontal to vertical pipe handler operational information to thesecond user 669.

The master control system can communicate with a drilling rig 680.

The drilling rig 680 can be sequentially connected and operationallyconnected to a vertical pipe handler 681, and a horizontal to verticalpipe handler 688.

The master controller operates a hoist system 682 of the rig, which isshown sitting on a subbase trailer, as this is a portable rig.

The hoist system includes a drawworks and a drill line 218 that connectsto a top drive 684. The master control for this embodied portable rigcan be used to control a winch 289 that runs a hoist line 287 forraising or lowering the mast 683 of the rig.

In this Figure, the master controller can also be used to operatehydraulic power tongs 689.

The drill line 218 passes from the drawworks to the crown 22 and then tothe top drive.

The hoist system 682 can have a rotational speed monitoring device 916that communicates to the master controller.

The rotational speed monitoring device 916 can be any device capable ofdetermining the rotational speed of the hoist system 682 andtransmitting the rotations per minute to the server in the computingcloud or on the network outside of the computing cloud.

The vertical pipe handler 681 can have one or more vertical pipe handlermonitoring devices 918 that can monitor the presence of each tubular 902and the device and determine pressure applied to each tubular connected,to the vertical pipe handler. The vertical pipe handler monitoringdevice 918 then transmits the signal to the server.

The vertical pipe handler monitoring devices 918 can be configured todetermine: (i) if the arms of the vertical pipe handler 681 areactuated, (ii) a position of the arms, or combinations thereof, andtransmit the information to the server in the computing cloud or on thenetwork outside of the computing cloud.

The top drive 684 can have one or more top drive monitoring devices 912.

The top drive monitoring devices 912 can be accelerometers, radiofrequency identification (RFID) tags, or any other device capable ofmeasuring the acceleration of the top drive 684 and/or aiding in thedetermination thereof by sending a signal or interacting with anothermonitoring device to cause a signal to be sent. In embodiments, the topdrive monitoring device is a device capable of measuring the location ofthe top drive.

For example, the top drive 684 can have a chip or device configured tointeract with one or more mast monitoring devices 914 to cause a signalto be sent to the server 602 a or 602 b or both between a crown and abase to detect where a top drive is located.

The hydraulic power tongs 689 can be power tongs secured to a drillfloor 690 of the drilling rig 680. The hydraulic power tongs 689 canhave one or more hydraulic power tong monitoring devices 928 configuredto determine if the hydraulic power tongs 689 are in a closed positionor opened position, determine forces applied to the hydraulic powertongs 689, or combinations thereof. The hydraulic power tong monitoringdevices can communicate with the servers in the computing cloud orconnected via the network to enable continuous monitoring of theapparatus.

The horizontal to vertical pipe handler 688 can have one or morehorizontal to vertical pipe handler monitoring devices 920 and 922configured to detect the location of the horizontal to vertical pipehandler 688, speed of the horizontal to vertical pipe handler 688, forceapplied to the horizontal to vertical pipe handler 688, the presence ofa tubular 902, how many tubulars are disposed on the horizontal tovertical pipe handler 688, the like, or combinations thereof. Thehorizontal to vertical pipe handler monitoring devices 920 and 922 cancommunicate to the servers in the computing cloud or connected via thenetwork.

The crown 22 can have a top crown 685 can have one or more top crownmonitoring devices 930 to determine the speed of line passingtherethrough and communicate to the servers in the computing cloud orconnected via the network.

Each of the monitoring devices, including the horizontal to verticalpipe handler monitoring devices 920 and 922, top crown monitoringdevices 930, rotational speed monitoring device 916, hydraulic powertong monitoring devices 928, mast monitoring devices 914, top drivemonitoring devices 912, and vertical pipe handler monitoring devices918, can communicate with a server 602 through any form of telemetry,such as through the network 608 or the computing cloud 687 usingindividual protocols of each sensor. Illustrative telemetry can includewired, wireless, acoustic, frequency, or combinations thereof.

The drilling rig 680 can be operatively aligned with a wellbore 698.

Also shown is a rig mounted sensor 929 that can be: used with computerinstructions in the data storage 610 for counting each tubular and/ormeasuring the length of each tubular that enters the wellbore 698.

FIG. 2 depicts the vertical pipe handler 681 with a tubular 902 adjacenta drilling rig 680.

The vertical pipe handler is shown with the top pivoting arm 904 holdingthe tubular 902 below a top drive 684 over the well center, and thebottom pivoting arm 905 also grasping the tubular 902. In this view thevertical pipe handler has raised the tubular from its position whengrasped from the horizontal to vertical pipe handler 688 above the baseof the rig.

FIG. 2 also shows a vertical pipe handler rotation and vertical motionmonitor 932. The vertical pipe handler rotation and vertical motionmonitor 932 transmits to the master control system a signal indicating adegree at which the vertical pipe handler is positioned and a height atwhich either the top pivoting arm 904, the bottom pivoting arm 905, orboth, are located from a base of the vertical pipe handler.

The top pivoting arm 904 can have a first arm monitor 934, and thebottom pivoting arm 905 can have a second arm monitor 936, which cancommunicate with the master control system to determine an angle ofextension of each pivoting arm on a vertical pipe handler and transmitthe angle of extension to the server.

Also shown in FIG. 2 are sensors that transmit signals on the locationof the tubular on the horizontal to vertical pipe handler 688.

The sensors for the horizontal to vertical pipe handler 688 include ahorizontal to vertical pipe handler tubular monitoring device 921transmitting information that a tubular is on the horizontal to verticalpipe handler 688 to the server.

The sensors for the horizontal to vertical pipe handler 688 include ahorizontal to vertical pipe handler tubular rolling monitoring device923 transmitting information that a tubular is rolling or stoppedrolling on the horizontal to vertical pipe handler to the server.

The sensors for the horizontal to vertical pipe handler include ahorizontal to vertical pipe handler grip monitoring device 925transmitting information that a tubular is gripped securely by thehorizontal to vertical pipe handler.

The mast 683 is also shown in this Figure.

FIGS. 3A and 3B depict a detailed schematic of data storage 610 aaccording to one or more embodiments.

The data storage 610 a can include computer instructions 620 to managesynchronized functions of the drilling rig a vertical pipe handler, anda horizontal to vertical pipe handler.

The data storage 610 a can include computer instructions 621 todetermine when a tubular is on a horizontal to vertical pipe handler.

The data storage 610 a can include computer instructions 624 to raisethe tubular from a horizontal position to a vertical position using thehorizontal to vertical pipe handler.

The data storage 610 a can include computer instructions 626 to extendtop and bottom pivoting arms of the vertical pipe handler.

The data storage 610 a can include computer instructions 627 to grab theraised tubular from the horizontal to vertical pipe handler using thetop and bottom pivoting arms.

The data storage 610 a can include computer instructions 629 to rotatethe extended pivoting arms holding the tubular to position the tubularover the well center.

The data storage 610 a can include computer instructions 629 to lift thetubular to a position proximate to the top drive for connection with thetop drive.

The data storage 610 a can include computer instructions 630 to lowerthe top drive down a mast of the drilling rig for connection to an endof the tubular.

The data storage 610 a can include computer instructions 631 to connectthe top drive to the tubular.

The data storage 610 a can include computer instructions 632 to rotatethe tubular using the top drive to insert the tubular into the wellborewhile lowering the top drive towards the well bore.

The data storage 610 a can include computer instructions 634 todisengage the tubular from the top drive once the tubular reaches apreset depth.

The data storage 610 a can include computer instructions 646 to retractthe top drive away from the wellbore.

The data storage 610 a can include computer instructions 661 to form anexecutive dashboard of rig functions, vertical pipe handler functionsand horizontal to vertical pipe handler functions.

The data storage 610 a can include computer instructions 638 forsimultaneously drilling with the drilling rig while connecting tubulars.

The data storage 610 a can include computer instructions 1000 formeasuring the length of each tubular that enters the well bore.

The data storage 610 a can include computer instructions 1002 forcounting each tubular with the rig mounted sensor as the top driveinserts the tubulars into the well bore.

The data storage 610 a can include computer instructions 1004 todetermine the speed of line passing there through and communicate to theservers via the web.

The data storage 610 a can include computer instructions 1006 to measureacceleration of the top drive.

The data storage 610 a can include computer instructions 1008 to measurelocation of the top drive.

The data storage 610 a can include computer instructions 1010 fordetermining a location of the top drive between the crown and thesubbase.

The data storage 610 a can include computer instructions 1012 todetermine a member of the group consisting of: if the hydraulic powertongs are in a closed position, if the hydraulic power tongs are in anopen position, how much torque force is applied to the hydraulic powertongs, or combinations thereof.

The data storage 610 a can include computer instructions 1014 to enabletransfer of a tubular between a horizontal to vertical pipe handler andan adjacent vertical pipe handler using signals from a vertical pipehandler monitoring device that can monitor the presence of each tubularand pressure applied to a tubular connected to the vertical pipehandler.

The data storage 610 a can include computer instructions 1016 forreceiving signals from: a horizontal to vertical pipe handler monitoringdevice for transmitting positions of the horizontal to vertical pipehandler holding the tubular to the server; a horizontal to vertical pipehandler tubular monitoring device transmitting information that atubular is on the horizontal to vertical pipe handler; a horizontal tovertical pipe handler tubular rolling monitoring device transmittinginformation that a tubular is rolling or stopped rolling on thehorizontal to vertical pipe handler; and a horizontal to vertical pipehandler grip monitoring device transmitting information that a tubularis gripped securely by the horizontal to vertical pipe handler.

The data storage 610 a can include computer instructions 1018 forreceiving signals from: a vertical pipe handler rotation and verticalmotion monitor for transmitting a degree at which the vertical pipehandler is positioned and a height at which either the top pivoting armthe bottom pivoting arm, or both; are located from a base of thevertical pipe handler; and a first arm monitor and a second arm monitorto determine an angle of extension of each pivoting arm on a verticalpipe handler and transmit the angle of extension to the server.

FIG. 4 is a detailed schematic of data storage 610 b according to one ormore embodiments.

The data storage 610 b can include computer instructions 620 to managesynchronized functions of the drilling rig, a vertical pipe handler anda horizontal to vertical pipe handler.

The data storage 610 b can include computer instructions 661 to form anexecutive dashboard of rig functions, vertical pipe handler functionsand horizontal to vertical pipe handler functions.

The data storage 610 b can include computer instructions 702 to lowerthe top drive to an end of a tubular disposed in the well bore.

The data storage 610 b can include computer instructions 704 to engagethe top drive with the tubular in the wellbore and rotating the tubularto make up a connection with the top drive.

The data storage 610 b can include computer instructions 706 to withdrawthe tubular from the wellbore.

The data storage 610 b can include computer instructions 708 to grab thetubular with a top and a bottom pivoting arms of a vertical pipehandler.

The data storage 610 b can include computer instructions 710 to retractthe top and bottom pivoting arms of the vertical pipe handler holdingthe tubular and rotate the top and bottom arms while lowering the topand bottom arms.

The data storage 610 b can include computer instructions 712 to grab thetubular from the vertical pipe handler with the horizontal to verticalpipe handler.

The data storage 610 b can include computer instructions 714 to lowerthe horizontal to vertical pipe handler holding the tubular and placingplace the tubular in a set back or a pipe tub.

The data storage 610 b can include computer instructions 716 forsimultaneously removing a drill string of connected tubulars from a wellbore while breaking up tubulars from a drill string.

The data storage 610 b can include computer instructions 2000 formeasuring the length of each tubular that are removed from the wellbore,and computer instructions 2002 for counting each tubular with the rigmounted sensor as the tubulars are removed from the wellbore.

FIG. 5 is a top view of an embodiment of the rig and vertical pipehandler and horizontal to vertical pipe handler that can be controlledby the master controller.

In this view can be seen the bucking machine 590 with a tubular 505 andthe pipe tub 592 connected to the vertical pipe handler 681 connected toa drilling rig 680.

While these embodiments have been described with emphasis on theembodiments, it should be understood that within the scope of theappended claims, the embodiments might be practiced other than asspecifically described herein.

What is claimed is:
 1. A system comprising: a data storage; and aprocessing device communicatively coupled to the data storage, theprocessing device to: receive a communication associated with acomponent of a remote drilling rig, wherein the component of the remotedrilling rig comprises a vertical tubular handler and the communicationassociated with the component of the remote drilling rig comprises anindication that a tubular is disposed on the vertical tubular handler;determine a position of the component of the remote drilling rig basedon the received communication; provide an executive dashboard thatincludes at least one drilling rig function associated with thecomponent of the remote drilling rig; initiate the remote drilling rigto perform the at least one drilling rig function associated with thecomponent of the remote drilling rig, wherein the at least one drillingrig function comprises using the remote drilling rig to grab the tubularby the vertical tubular handler or raise the tubular to a verticalposition from an initial horizontal position; and responsive to theremote drilling rig being initiated to grab the tubular, send a signalto the vertical tubular handler to extend at least one pivoting arm tograb the tubular from the initial horizontal position.
 2. The system ofclaim 1, wherein the component of the remote drilling rig comprises ahoist system, wherein the communication associated with the component ofthe remote drilling rig comprises a sensed position and rotational speedof the hoist system, wherein the processing device is to determine adepth of a tubular in a well bore based on the sensed position androtational speed of the hoist system.
 3. The system of claim 2, whereinthe at least one drilling rig function comprises actuating the verticaltubular handler based on the determined depth of the tubular in the wellbore.
 4. The system of claim 2, wherein the component of the remotedrilling rig comprises a top drive, wherein the processing device is todetermine a location of the top drive based on the sensed position androtational speed of the hoist system.
 5. The system of claim 4, whereinthe at least one drilling rig function comprises actuating the verticaltubular handler based on the location of the top drive.
 6. The system ofclaim 1, wherein the communication associated with the component of theremote drilling rig comprises at least one of: installing, moving orremoving a tubular.
 7. The system of claim 1, wherein when determiningthe position of the component, the processing device is to identify asensed location of a top drive based on the communication, wherein wheninitiating the remote drilling rig to perform the at least one drillingrig function, the processing device is to actuate the vertical tubularhandler based on the sensed location of the top drive.
 8. The system ofclaim 1, wherein the executive dashboard further includes tubularhandler operation information for at least one of a vertical tubularhandler or a horizontal tubular handler.
 9. The system of claim 1,wherein when initiating the remote drilling rig to perform the at leastone drilling rig function associated with the component of the remotedrilling rig, the processing device is to: receive input pertaining toat least one drilling rig function via the executive dashboard; andtransmit an instruction to the drilling rig to perform the at least onedrilling rig function that pertains to the received input.
 10. A systemcomprising: a server communicatively coupled to a remote drilling rig,the server comprising: a data storage; and a processing devicecommunicatively coupled to the data storage, the processing device to:receive a communication associated with a component of the drilling rig,wherein the component of the remote drilling rig comprises a verticaltubular handler and the communication associated with the component ofthe remote drilling rig comprises an indication that a tubular isdisposed on the vertical tubular handler; determine a position of thecomponent of the remote drilling rig based on the receivedcommunication; provide an executive dashboard to a client device thatincludes at least one drilling rig function associated with thecomponent of the remote drilling rig; receiving an instruction from theclient device to perform the at least one drilling rig function;initiate the remote drilling rig to perform the at least one drillingrig function associated with the component of the remote drilling rig,wherein the at least one drilling rig function comprises using theremote drilling rig to grab the tubular by the vertical tubular handleror raise the tubular to a vertical position from an initial horizontalposition; and responsive to the remote drilling rig being initiated tograb the tubular, send a signal to the vertical tubular handler toextend at least one pivoting arm to grab the tubular from the initialhorizontal position.
 11. The system of claim 10, wherein the componentof the remote drilling rig comprises a hoist system, wherein thecommunication associated with the component of the remote drilling rigcomprises a sensed position and rotational speed of the hoist system,wherein the processing device is to determine a depth of a tubular in awell bore based on the sensed position and rotational speed of the hoistsystem.
 12. The system of claim 10, wherein the communication associatedwith the component of the remote drilling rig comprises at least one of:installing, moving or removing a tubular.
 13. A non-transitory computerreadable storage medium comprising instructions that, when executed by aprocessing device, cause the processing device to perform operationscomprising: receiving a communication associated with a component of aremote drilling rig, wherein the component of the remote drilling rigcomprises a vertical tubular handler and the communication associatedwith the component of the remote drilling rig comprising an indicationthat a tubular is disposed on the vertical tubular handler; determining,by the processing device, a position of the component of the remotedrilling rig based on the received communication; providing an executivedashboard that includes at least one drilling rig function associatedwith the component of the remote drilling rig; initiating, by theprocessing device, the remote drilling rig to perform the at least onedrilling rig function associated with the component of the remotedrilling rig, wherein the at least one drilling rig function comprisesgrabbing the tubular by the vertical tubular handler or raising thetubular to a vertical position from an initial horizontal position; andresponsive to the remote drilling rig being initiated to grab thetubular, sending a signal to the vertical tubular handler to extend atleast one pivoting arm to grab the tubular from the initial horizontalposition.
 14. The non-transitory computer readable storage medium ofclaim 13, wherein the component of the remote drilling rig comprises ahoist system, wherein the communication associated with the component ofthe remote drilling rig comprises a sensed position and rotational speedof the hoist system, wherein the processing device is to determine adepth of a tubular in a well bore based on the sensed position androtational speed of the hoist system.
 15. The non-transitory computerreadable storage medium of claim 13, wherein the executive dashboardfurther includes tubular handler operation information for at least oneof a vertical tubular handler or a horizontal tubular handler.